Tyra Field | |
---|---|
![]() Platform at Tyra East | |
Country | Denmark |
Region | North Sea |
Block | 5504/11 5504/12 |
Offshore/onshore | offshore |
Operator | Total |
Partners | Total Noreco Nordsofonden |
Field history | |
Discovery | 1968 |
Start of production | 1984 |
Production | |
Current production of gas | 237.8×10 6 cu ft/d (6.73×10 6 m3/d) |
Estimated gas in place | 1,250×10 9 cu ft (35×10 9 m3) |
Producing formations | Danian and Upper Cretaceous Chalk |
Tyra Field is the largest gas condensate field in the Danish Sector of the North Sea. [1] It was discovered in 1968 and production started in 1984. [2] The field is owned by Dansk Undergrunds Consortium, a partnership between Total, BlueNord and Nordsofonden, and operated by Total. [3] The reservoir depth is about 2,000 metres (6,600 ft) and it covers area of 90 kilometres (56 mi) in the water depth of 37–40 metres (121–131 ft). [2] The Tyra field has a number of satellite fields, including Roar, Svend and Tyra Southeast fields.
In August 2017 Maersk Oil was sold to Total S.A. with the takeover completed in 2018.
The Tyra Field has two production complexes named Tyra West and Tyra East, connected by pipelines. Tyra West includes oil and gas processing plants which in addition to the gas produced at the Tyra field, processes also gas from Halfdan field and the Valdemar oil field. The complex consists of two wellhead platforms, one processing and accommodation platform, and one gas flare stack. Tyra East processes also oil and gas from Valdemar, Roar, Svend, Tyra Southeast, Harald gas field, Lulita, Gorm and Dan oil fields. It consists of two wellhead platforms, one processing and accommodation platform, one gas flare stack, and one riser platform. [2]
The installations developed for the Tyra field were: [4]
Installation | Location Block | Platforms | Function | Type | Legs | Well slots | Installed | Production start | Production to |
---|---|---|---|---|---|---|---|---|---|
Tyra West | 6.2 | TW-A | Processing (2 x 135 MMSCFD) | Steel jacket | 4 | – | March 1982 | May 1984 | TE-E |
TW-B | Drilling & wellhead | Steel jacket | 4 | 12 | March 1982 | May 1984 | TW-A | ||
TW-C | Drilling & wellhead | Steel jacket | 4 | 12 | May 1983 | 1985 | TW-A | ||
TW-D | Flare | Steel jacket | 3 | – | April–May 1983 | – | – | ||
TW-E | Production | Steel jacket | 1984 | ||||||
Tyra East | 6.2 | TCP-A | Processing (2 X 135 MMSCFD) & accommodation | Steel jacket | 8 | – | March–June 1983 | June 1984 | TE-E |
TE-B | Drilling & wellhead | Steel jacket | 4 | 12 | February 1983 1982 | June 1984 | TCP-A | ||
TE-C | Drilling & wellhead | Steel jacket | 4 | 12 | May 1983 | 1985 | TCP-A | ||
TE-D | Flare | Steel jacket | 3 | – | April–May 1983 | – | – | ||
TE-E | Riser | Steel jacket | 4 | – | March 1982 | 1984 | Jutland onshore | ||
TE-F | Production | Steel jacket | 1995 |
In total, the field has 20 gas-producing wells, and 28 oil and gas-producing wells. [2]
Fluids from the drilling & wellhead platforms are routed to an inlet three phase inlet separator on the ‘A’ processing platforms. The separator separated the fluids into gas, condensate and produced water. Gas undergoes water dehydration through contact with glycol. On TCP-A the gas is comingled with gas from Gorm, Dan and Tyra West. The combined gas stream is chilled to achieve a hydrocarbon dewpoint. The gas is compressed from 1000 to 2000 psi (pounds-force per square inch) in 5 Ruston TB5000 gas turbine driven gas compressors (24,500 brake horse power total), and is fiscally metered before export onshore to Jutland. The design export rate is 11.5 million cubic metres (405 million cubic feet ) per day at standard conditions. [4]
Condensate from the inlet separator is routed to a coalescer after which it is comingled with condensate from Tyra West. The combined stream is routed successively through a 1st stage, 2nd stage and 3rd stage separators operating at successively lower pressures. Gas from the 2nd and 3rd stage separators is compressed and joins the gas from the 1st stage separator and is routed into the inlet separator. Condensate from the 3rd stage separator is fiscally metered and is exported onshore via the Gorm installation. The design export rate is 20,000 barrels/day. [4]
Produced water from the inlet separator is treated to remove and condensate and is discharged overboard. [4]
Produced oil is transported to the Gorm E riser platform in the Gorm field, and further through the subsea pipeline to the oil terminal in Fredericia, Denmark. Produced natural gas is transported from the Tyra East riser platform to Nybro Gas Processing Plant, Denmark, and from Tyra West riser platform to the Netherlands through the Tyra West – F3 and NOGAT pipelines. [5]
Due to the production facilities having sunk 6m Maersk Oil announced on 1 December 2017 Maersk Oil the redevelopment of Tyra Field, which would mean decommissioning the 35 year old facilities and installing new ones. [6] [7] The living and processing platform on Tyra East and Tyra West will be scrapped. One new living platform and one new processing platform will be built. The living quarter platform will be constructed by Italian EPC contractor Rosetti marino, while processing platform will be constructed in Kuala Lumpur by American EPC contractor McDermott International.
In July 2018 Modern American Recycling Services based in Frederikshavn secured a contract to scrap the two platforms. [8]
Up until the temporary closure in September 2019, the Tyra field processed 90% of all gas produced in the Danish part of the North Sea.[ needs update ] [6]
The decommission project is estimated to cost 4 Billion DKK and the new facilities will cost 17 Billion DKK. All in all the project is expected use 1.3 million working hours. [9]
The new facilities were planned to be ready for production in July 2022, but this was postponed to July 2023 due to the COVID-19 pandemic. [9]
The Tyra field has a number of satellite fields. These include Roar, Svend and Tyra Southeast fields.
The characteristics of the satellite fields are as follows. [10]
Field | Roar | Svend | Tyra Southeast |
Prospect | Bent | North Arne / Otto | |
Reservoir | Chalk | Chalk | Chalk |
Geological age | Danian and Upper Cretaceous | Danian and Upper Cretaceous | Danian and Upper Cretaceous |
Coordinates | 55.767485°N 4.64839°E | 56.178324°N 4.179324°E | 55.639618°N 4.882641°E |
Block | 5504/7 | 5604/25 | 5504/12 |
Reservoir depth | 2,025 m | 2,500 m | 2,050 m |
Field delineation | 84 km2 | 48 km2 | 142 km2 |
Reserves | Oil 0.1 million m3 Gas 1.7 billion Nm3 | Oil 0.5 million m3 Gas 0.1 billion Nm3 | Oil 7.7 million m3 Gas 16.5 billion Nm3 |
Discovered | 1968 | 1975 North Arne, 1982 Otto | 1992 |
The Roar, Svend and Tyra Southeast fields are developed through three offshore installations as shown. [10] [11]
Field | Roar | Svend | Tyra Southeast |
Production start | 1996 | 1996 | 2002 |
Water depth | 46 m | 65 m | 39 m |
Installation | Steel STAR platform | Steel STAR platform | Steel STAR platform |
Function | Wellhead, separation | Wellhead | Wellhead, separation |
Substructure weight tonnes | 950 | 1150 | 880 |
Topsides weight tonnes | 550 | 575 | 550 |
Number of wells | 4 gas | 4 | 2 oil, 5 gas |
Status | Closed 2019 | Closed 2015 | Closed 2019 |
Export, well fluids | 11 km 16-inch multiphase pipeline to Tyra East | pipeline to Tyra East | pipeline to Tyra East |
The oil and gas production profile of the Roar, Svend and Tyra Southeast fields is as shown.
Year | 1996 | 1997 | 1998 | 1999 | 2000 | 2001 | 2002 | 2003 | 2004 | 2005 | 2006 | 2007 | 2008 | 2009 | 2010 |
Roar | 320 | 427 | 327 | 259 | 285 | 317 | 175 | 121 | 98 | 94 | 51 | 35 | 28 | 30 | 24 |
Svend | 836 | 1,356 | 635 | 521 | 576 | 397 | 457 | 280 | 326 | 324 | 296 | 299 | 278 | 195 | 190 |
Tyra Southeast | 493 | 343 | 580 | 614 | 446 | 377 | 429 | 374 | 225 |
Year | 2011 | 2012 | 2013 | 2014 | 2015 | 2016 | 2017 | 2018 | 2019 | 2020 | 2021 | 2022 | Total |
Roar | 16 | 2 | 4 | 6 | 6 | 8 | 82 | 100 | 76 | 2,891 | |||
Svend | 145 | 171 | 183 | 160 | 136 | 7,759 | |||||||
Tyra Southeast | 165 | 148 | 98 | 91 | 118 | 283 | 383 | 316 | 162 | 5,644 |
Year | 1996 | 1997 | 1998 | 1999 | 2000 | 2001 | 2002 | 2003 | 2004 | 2005 | 2006 | 2007 | 2008 | 2009 | 2010 |
Roar | 1,332 | 1,964 | 1,458 | 1,249 | 1,407 | 1,702 | 1,052 | 915 | 894 | 860 | 489 | 367 | 417 | 398 | 213 |
Svend | 85 | 152 | 84 | 65 | 75 | 48 | 61 | 43 | 38 | 34 | 28 | 28 | 24 | 16 | 27 |
Tyra Southeast | 447 | 452 | 1,233 | 1,337 | 1,108 | 848 | 889 | 939 | 911 |
Year | 2011 | 2012 | 2013 | 2014 | 2015 | 2016 | 2017 | 2018 | 2019 | 2020 | 2021 | 2022 | Total |
Roar | 171 | 24 | 28 | 46 | 40 | 46 | 264 | 278 | 194 | 15,809 | |||
Svend | 24 | 27 | 20 | 16 | 15 | 908 | |||||||
Tyra Southeast | 626 | 610 | 306 | 201 | 248 | 554 | 981 | 734 | 391 | 12,816 |
The Everest gasfield is located in the Central North Sea, 233 kilometres (145 mi) east of Aberdeen, Scotland. It lies in the United Kingdom Continental Shelf blocks 22/9, 22/10a and 22/14a. The gasfield was discovered by Amoco in 1982 with first gas produced in 1993.
The Central Area Transmission System is a natural gas transportation and processing system that transports natural gas through a 404 kilometre pipeline from the Central North Sea to a reception and processing terminal at Teesside in the North East of England.
Gorm is a natural gas and oilfield in the Danish Sector of North Sea. It was discovered in 1971 and is the largest oilfield exploited by Denmark. The production infrastructure consists of five bridge-linked platforms and is operated by BlueNord. The facilities include two wellhead platforms and several processing platforms. The Rolf and Dagmar fields are satellites to Gorm.
Gannet is an oil and gas field located in the United Kingdom's continental shelf in the North Sea. It is 180 km (110 mi) east of Aberdeen, and the water depth at the Gannet offshore installation is 95 m (312 ft). The field is located in Blocks 22/21, 22/25, 22/26 and 21/30. It is half-owned by Royal Dutch Shell (50%) and partly by ExxonMobil (50%) and has been operated by Shell UK Ltd since ‘first oil’ in November 1993. The Gannet A installation is the host platform for subsea tiebacks designated Gannet B to G. Like most Shell fields in the central and northern North Sea the field is named after a sea bird the gannet.
The Dan oil field is a large oil and associated gas field in the Danish sector of the North Sea, about 200 kilometres (120 mi) west of Esbjerg. Oil and gas are produced through a complex of offshore installations. The Kraka and Regnar fields are satellites to the Dan installations.
Alwyn North is a major oil and gas field in the United Kingdom sector of the northern North Sea, 160 km east of the Shetland Islands. The field was developed through two bridge-linked offshore platforms and a number of subsea satellite wellheads. Alwyn North has been producing oil and gas since 1987 and is still (2023) in operation.
The Beryl oil field is a major crude oil production field in the UK sector of the northern North Sea, 335 km north east of Aberdeen. Production of oil started in 1976 and the field is still producing oil and gas (2021).
The Ravenspurn gas fields are two adjacent natural gas fields located in the UK sector of the southern North Sea about 65 km east of Flambrough Head, Yorkshire.
The Lincolnshire Offshore Gas Gathering System (LOGGS) was a major natural gas collection, processing and transportation complex in the UK sector of the southern North Sea. It comprised five bridge-linked platforms about 118 km east of the Lincolnshire coast, which operated from 1988 to 2018.
The Pickerill and Juliet gas fields are decommissioned natural gas producing facilities in the UK sector of the southern North Sea. The fields are located about 66 km (41 mi) east of Spurn Head, Lincolnshire. Pickerill was in operation from 1992 until 2018 and Juliet from 2014 to 2018.
The Tyne, Trent and Tors gas fields are depleted natural gas reservoirs and former gas production facilities in the southern North Sea, centred around the Trent installation about 115 km east of Flamborough Head, Yorkshire. The fields produced gas from 1996 to 2020.
The Cleeton gas field and hub is a natural gas production, gathering, compression, treatment and transportation facility in the southern North Sea, 54 km east of Flamborough Head, Yorkshire. It has been producing and transmitting gas since 1988.
The Skjold oil field is a crude oil and associated gas production field in the Danish sector of the central North Sea, close to the Danish-German median line. Production of oil started in 1982, peak oil was achieved in 1991 and production is expected to continue until 2038.
Halfdan is a significant oil and gas field in the south-western part of the Danish sector of the southern North Sea. The field has been in production since 1999. The Sif and Igor fields are satellites to Hallfdan.
The Siri oil field and its satellites, Nini and Cecille, are oil producing fields in the Danish sector of the southern North Sea. Operating since 1999 and 2003 they are the most northerly of Denmark's offshore oil assets located close to the Denmark-Norway median line.
The Valdemar oil and gas field is a crude oil and gas production field in the Danish sector of the central North Sea. Production of oil and gas started in 1993, peak oil was achieved in 2009 and peak gas in 2010. Production was suspended in 2019.
The South Arne field is a major crude oil and associated gas production field in the Danish sector of the central North Sea. Production of oil and gas started in 1999, and peak oil and gas was in 2000.
The Harald field is a gas and associated condensate production field in the Danish sector of the central North Sea. Production of gas and liquids started in 1997, and peak gas was in 1998. The Lulita field is a satellite of the Harald field.
Ravn is a marginal oil field in the Danish sector of the North Sea. It started operating in 2017, with oil exported to an installation in the German sector of the North Sea. Operations were suspended in 2020, and decommissioning is currently being planned.